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Home My WebLink About201-043 STATE OF ALASKA • KA OIL AND GAS CONSERVATION COMAION - REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well Li Plug Perforations Li Perforate U Other Lf Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ • Stimulate - Other lig Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 201 -043 -0 • 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22191 -01 -00 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028288 PBU Y -26A ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL ' 11. Present Well Condition Summary: Total Depth measured 11822 feet • Plugs measured None feet true vertical 8987 feet Junk measured None feet Effective Depth measured 11761 feet Packer measured 10344 feet true vertical 9003.38 feet true vertical 8667.29 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" Conductor 30 - 110 30 - 110 0 0 Surface 2636 10 -3/4" 45# L -80 29 - 2665 29 - 2664.78 5210 2480 Intermediate None None None None None None Production 10641 7 -5/8" 29.7# NT -95HS 28 - 10669 28 - 8910.92 8180 5120 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10883 - 10949 feet 11046 - 11112 feet 11305 - 11761 feet True Vertical depth 9004.07 - 9018.74 feet 9038.87 - 9052.95 feet 9071.26 - 9003.38 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 27 - 10400 27 - 8709.23 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 10344 8667.29 Packer None None None SSSV 12. Stimulation or cement squeeze summary: JUN i Intervals treated (measured): SCANNED �1�1� u 10883' - 10949', 11046' - 11112', 11305' - 11761' Treatment descriptions including volumes used and final pressure: t�i 52 BBL 12% HCL, 823 BBL 1% KCL W /SAFELUBE, 41 BBL POWERVIS, 360 BBL NH4CL, 42 BBL 9.1 HCUHF MUD ACID 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 198 228 732 1508 278 Subsequent to operation: 152 334 1007 1851 286 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratori❑ Development ig ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El • Gas ❑ WDSPI J GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Email Nita.SummerhaysaBP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician ,-1r/ Si g '�,i�i# /� �/� Phone 564 -4035 Date 6/12/2013 R DMS JUN 14 10 t3`� k`i4 /1 3 , dt Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028288 T /I /O = 1730/1720/120. Temp = SI. TIFL - PASSED (Pre -Mud acid stim). AL SI © casing valve (1840 psi). Initial IA FL @ 10140' (170' above Sta #1, SO, 266 bbls). Initial TBG FL @ 3283 ( 300' below sta #6, dome, 50 bbls). Bled IAP to production from 1720 psi to 660 psi in 1 hour and 45 minutes. During the bleed, TP decreased 20 psi with no change in the IA fluid level. Monitored for one hour, IAP remained unchanged, IA fluid level remained unchanged (See log tab for details). Well returned to Ops to POP. Job Complete. FWP's = 1710/660/120. 5/7/2013 SV, WV = SI. SSV, MV = O. IA, OA = OTG. NOVP. 1615 hrs. ASRC Well Test Unit #2, FCO w /CTU Acid and Test, Inlet well Y -26, Outlet well Y- 13, Spot up on Y -pad, STBY for Grease Crew and QC crew, * *Continue on WSR - 5/9/2013 05/10/13 ** ASRC Well Test Unit #2, * *Cont. from WSR 05/09/13* *STBY for grease crew, 5/10/2013 Begiin RU, RU complete, STBY * *Continue on WSR 05/11/13 ** ASRC Well Test Unit #2, * *Cont. from WSR 05/10/13 * *RU complete, PT complete, 5/11/2013 STBY for CTU, * *Continue on WSR 05/12/13 ** ASRC Well Test Unit #2, * *Cont. from WSR D5/11/13 ** PT complete, STBY for 5/12/2013 CTU, * *Continue on WSR 05/13/13 ** ASRC Well Test Unit #2, * *Cont. from WSR 05/12/13 ** * *FCO ACID & Test ** RU 5/13/2013 complete, PT complete, STBY for CTU, * *Continue on WSR 05/14/13 ** ASRC Test Unit 2 Test & C1 U FCO and Acid Assist. ** *Continued on from WSR 5/13/13 Inlet well Y -26. Outlet well Y -13. Continue to S/B for CTU. ** *Continued on to WSR 5/15/13 * ** 5/14/2013 ASRC Test Unit #2 * *Continued from WSR 5/14/13 FCO, ACID & TEST with CTU, 5/15/2013 Cont. SB for CTU, Inlet well Y26, Outlet well Y -13, * *Continued on 5/16/13 ** ASRC Test Unit #2 * *Continued from WSR 5/14/13 FCO, ACID & TEST with CTU, CTU on location, MIRU, Inlet well Y26, Outlet well Y -13, * *Continued on 5/16/13 ** 5/16/2013 Weekly Drills ending 5 -3 -2013 CTU #6 - 1.75" coil Scope: Drift, Acid Treatment MIRU from R -28. PT PCE and load fluids. Wait on HCL. « <Job In Progress »> 5/16/2013 CTU #6 - 1.75" coil Scope: Drift, Acid Treatment Pickle Coil with 10 bbls 12% HCL. POP well and RIH. SI well and cont. RIH. Set down soft at 10740', online with pump, jet down to 10951' sat down hard, Attempted to jet on obstruction with multiple tags. No hole made. POOH. Tested BOP's. MU MHA with 2.30" mill. Stab onto well, RIH. Work through crossover at 10888' CTM, RIH to 10946', Time mill, Wiper to 10,300'. « <Job In Progress »> 5/17/2013 ASRC 1 est Unit #2 * *Continued from WSR 5/16/13 * ** I-CO, ACID & TEST with CTU. STBY for CTU. POP Well. S/I Well. STBY for CTU. Inlet Well Y -26. Outlet 5/17/2013 Well Y -13. * *Continued on WSR 5/18/13 ** Repop well * ** ASRC Test Unit #2 * *Continued WSR 5/17/13 ** FCO, ACID & TesT. Continue Assisting CTU w/ Mill. Inlet Well Y -26. Outlet Well Y -13. * *Continued on WSR 5/18/2013 5/19/13 ** Continue standby for CTU * ** • • Daily Report of Well Operations ADL0028288 CTU #6 - 1.75" coil Scope: Drift, Acid Treatment Mill ahead from 10,946' with several stalls, RIH from 10,946' to 10,993'. Mill from 10,993 to 10,995' with several stalls. Stuck pulling of bottom at 10985'. Worked pipe, Jar down and up several times. SI well and bleed down, Bullhead 144 bbls of 1% KCL + Safelube down backside, Jar down 10 times, Mill came free, Backream. POOH. LD Milling BHA, Mill had 3/4" piece of 3/16" diameter steel in nose. Perform post jar inspection on injector. « <Job In Progress »> 5/18/2013 ASRC Test Unit #2 **Continued from WSR 5/18/13** I-CO, ACID & Test. Assisting CTU w/ Acid. CTU Pumping Acid. Inlet Well Y -26. Outlet Well Y -13. **Continued on 5/19/2013 WSR 5/20/13** CTU #6 - 1.75" coil Scope: Drift, Acid Treatment MU 1.75" nozzle BHA. PT PCE. RIH. Perform Injectivity test, 1.5 BPM at 1500 psi WHP. Load tubing w/ 200 bbls of 3% NH4CL + FP. Pump acid treatment (3 stages of 14 bbls 12% HCL, 14 bbls 9:1 Mud Acid, 21 bbl 3% NH4CL overflush, 14 bbls OilSeeker diversion). Stage #1 - 630 psi WHP drop, 370 psi diversion. Stage #2 - 320 psi WHP drop, 325 psi diversion. Stage 3# 50 psi WHP drop. POOH. DVI, LD BHA. RDMO 5/19/2013 « <Job Complete »> ASRC Test Unit #2 * *Continued from WSR 5/19/13 ** FCO, Acid & 12 Hr Test. POP Well. Inlet Well Y -26. Outlet Well Y -13. * *Continued on WSR 5/21/13 ** Stabilizing 5/20/2013 well * ** ASRC Test Unit #2 * *Continued from WSR 5/20/13 ** FCO, Acid & 12 Hr Test. Continue To Open up/ Stabilize Well. Perform 12 Hr Test. Inlet Well Y -26. Outlet 5/21/2013 Well Y -13. * *Continued on WSR 5/22/13 * ** End 12 hr.,well test ** *Begin rig down * ** ASRC Test Unit #2 * *Continued from WSR 5/21/13 * ** RDMO * * *. Inlet Well Y -26. 5/22/2013 Outlet Well Y -13. * *Continued on WSR 5/23/13 ** Move on to Y -9 * ** T /I /O = 270/1350/160. Temp = 104 °. TIFL (Post acid stim). PASS. AL online, ALP = 1350 psi. Initial IA FL © 10310' (sta # 1, SO). Shut in AL © casing valve & SI wing. Stacked out well using AL gas to 1500/1350/160. Bled IAP from 1350 psi to 300 psi in 1.5 hrs to production. During bleed the tubing pressure decreased 40 psi, OAP decreased 20 psi & IA FL unchanged. Monitored for 1 hr. TP increased 20 psi. IAP , OAP & IA FL unchanged. Well returned to Ops to POP. See Job Log for details. Job complete. Final WHPs = 1480/300/140. 5/23/2013 SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 1400. FLUIDS PUMPED BBLS 296 60/40 METH 52 12% HCL 823 1% KCL W /SAFELUBE 41 POWERVIS 360 NH4CL 40 DIESEL . • • Daily Report of Well Operations ADL0028288 42 9.1 HCL/HF MUD ACID 28 OIL SEEKER DIVERSION 511 TOTAL Casing / Tubing Attachment ADLOO28288 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" Conductor 30 - 110 30 - 110 LINER 537 3 -1/2" 9.3# L -80 10344 - 10881 8667.29 - 9003.62 10160 10530 LINER 914 2 -7/8" 6.16# L -80 10881 - 11795 9003.62 - 8994.5 13450 13890 PRODUCTION 10641 7 -5/8" 29.7# NT -95HS 28 - 10669 28 - 8910.92 8180 5120 TUBING 10373 4 -1/2" 12.6# 13Cr80 27 - 10400 27 - 8709.23 8430 7500 SURFACE 2636 10 -3/4" 45# L -80 29 - 2665 29 - 2664.78 5210 2480 LINER 269 5 -1/2" 17# NT13FL4S 10398 - 10667 8707.74 - 8909.43 • • TREE = 4- 1/16 " - 5M CM, NOTE WEt ANGLE > TO° 10798' "* VVELLHEAD 11 "- BA Y -26A 4-1/2" CH TBG & ,�- Eft NR*'* KB. ELEV = 87.65' BF.EEV= 51.11' KOP __.._ 3400' I 2094' H4 -1/2" OTIS WO SSSVN NP, HD = 3.813" 1 Mex Angle = 106° (-, 11753' • Datum MD = 10638' Datum TVD= 8800' SS GAS LFT MANDRELS 10 -3/4" CSG, 45.5#, NT -80, D= 9.953" H 2666• ST MD TVD DEV TYPE VLV LATCH FORT' DATE 6 2986 2987 3 CAM DOME BK 16 05/26/12 5 5496 5097 49 CAM DONE BK 16 05/26/12 4 7495 6498 43 CAM DMY BK 0 01/13/06 Minimum ID = 2.372" @ 10881' 3 8818 7479 39 CAM DONE BK 16 05/26/12 3 -1/2" X 2 -718" LINER XO 2 9702 8173 40 CAM DM( BK 0 07/31/01 1 10310 8642 41 CAM SO BK 20 05/26/12 I 1 10337' 1 - 14 - 1/2" FKR SWS NF, D = 3.813" i 13.70" BKR LNR DEPLOY SLV , D= 3.00" H 10344' I 10344' H 7- 5/8'X4 - V2' BKR S-3 FKR, D = 4.00" 13 LP, 9.3#, L - 80, STL, ID = 2.99' H 10346' . 1 I I I 10366' 1 FKR SWS N? D = 3.813' I I I 10387' 1 14 - 1/2" FKR SWN NP, D= 3.725' I 17 -5/8" X 5-1/2" TM/ LNR HGR & TEBACK —1 10398' 10400' H4 -1/2" 1M-EG, D= 3.958" 1 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, D= 3.958' H 10399' 17 -5/8' CSG, 29.7 #, NT95HS, D = 6.875" H 10669' IA j 5-1/2" NTL Lour vua�DOW (Y -26A) 10667' - 10674' I WHPSTOCK —I 1 0666' 1 RA TAG 10675' ► 10881' 1-1 3-1 /2" LNR X 2 -7/8' LNR XO, D = 2.347" , � 1 �1�1�1� 1 v 1 v 1 S PERFORATION ►*� ` 4 ` PBZFORATtU . REF LOG: 13111( INTE3a) NM) LOG OF 8/15/01 .'��.�1'1.4 4 ` . ` ANGLE AT TOP PEW: 77° �� 10883' ••••••1 ` . Note: Refer to Production DB for historical pert data 11111111111111 `. 1•••••• SIZE SPF NTHi1/AL Opn/Sqz DATE 11111111111111 \ ■ . 2 -7/8" SLID 10883 - 10949 0 08/17/01 11•1•1•1•1•1• 1 55 1111111 2 -7/8" SLID 11096 - 11112 0 08/17/01 1111111 ` 2 -7/8" SLID 11305 - 11761 0 08/17/01 • 1 ` ►••••••1 . ► 1 1 PBTO 11761' I 1 5-1/2" LNR, 17#, 13CR FL4S, D = 4.892" H 1108T .•.......•'••• I2 -7/8' LNR, 6.16#, L-80, STL, .0058 bpf, D = 2.347" I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/30/91 MJL ORIGINAL COMPLETION 05/30/12 G1B/J110 GLV C/O (05/26/12) MIL: Y -26A 08/17/01 CWKAK CM SIDETRACK 07/16/12 JRR'JMD SET PX PLUG (07/13/12) PERMIT No: " 10/23/01 AF /CH PERF & LNR CORRECTIONS 01/17/13 SWC/JMO PULLED PX PLUG (01/08/13) API No: 50- 029 - 22191 -01 01/22/06 KSB/TLH GLV CJO (01/13/06) SEC 33, T11N, R13E, 1472' FNL & 494' FEL, 12/21/07 JPK/T1J1 GLV TVD CO TTONS 02/09/08 KJB/PJC GLV FORT CORRECTION BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 20, 2010 51wittiNe 341\ ♦ Y Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 t1(ll`, 333 West 7th Avenue Anchorage, Alaska 99501 " � n 9 f,011S- C "- : sion Subject: Corrosion Inhibitor Treatments of GPB Y Pad Dear Mr. Maunder, \./ - 491-1 Enclosed please find multiple copies of a spreadsheet with a list of wells from Y Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to *event water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 12/20/10 Corrosion Well Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal Y -01B 2010760 50029203940200 NA 2.5 NA 8.50 4/11/2010 Y -02A 2011730 50029203950100 NA 0.1 NA 0.85 4/11/2010 Y - 03A 2042350 50029204110100 NA 2.2 NA 18.70 4/16/2010 Y - 04 1791050 50029204230000 NA 1 NA 5.10 4/11/2010 Y -05B 2081380 50029204360200 NA 3.3 NA 20.40 4/15/2010 Y - 06A 2042510 50029204310100 NA 0.7 NA 3.40 4/16/2010 Y - 07A 2071050 50029205600100_ 14.5 2.0 0.3 NA 1.70 8/4/2010 Y -08A 1880560 50029205720100 NA 4 NA 15.30 8/5/2010 Y - 09A 1970830 50029205790100 19 1.5 3.6 _ NA 17.00 8/4/2010 Y -10A 2042500 50029205870100 19 3.0 8.75 NA 54.40 8/6/2010 Y - 11C 2051640 50029205130300 NA 0.1 NA 0.90 4/14/2010 Y -13 1811120 50029206340000 NA 0.4 NA _ 3.40 4/15/2010 Y -14B 2011010 50029218320200 NA 3.8 NA 20.40 4/10/2010 Y -15A 2010890 50029209400100 NA ,2.1 NA 11.90 4/10/2010 Y -16 1830490 50029209320000 18.8 2.0 1.7 NA 10.20 8/4/2010 Y -18 1830290 50029209160000 NA 0.8 NA 5.10 4/9/2010 Y - 19 1880960 50029218570000 NA 0.2 NA 0.85 4/15/2010 Y - 20A 2010250 50029215870100 NA 1.5 NA 11.90 4/14/2010 Y - 21A 1 950 37 0 50029215740100 NA 0.1 NA 1.70 4/13/2010 Y -22A 1881150 50029215580100 NA 0.5 NA 3.40 8/4/2010 Y -23B 2031640 50029215900200 NA 1.2 NA 6.80 4/13/2010 Y -24 1861130 50029216080000 NA 1 NA 6.80 4/12/2010 Y - 25A 2081400 50029218830100 NA 0.3 NA 1.70 4/18/2010 Y -26A 2010430 50029221910100 NA 0.3 NA 1.70 4/15/2010 Y - 27 1 90028 0 50029220190000 NA 0.5 NA 3.40 4/14/2010 Y -28 1910650 50029221690000 NA 3.5 NA 28.90 4/12/2010 Y - 29A 1 96091 0 50029221230100 _ NA 0.2 NA 1.70 4/13/2010 Y - 30 1910150 50029221350000 NA 0.5 NA 2.60 4/13/2010 Y -31 1910560 50029221610000 NA 0.5 NA 3.40 4/12/2010 Y - 32 1910410 50029221490000 NA 0.3 NA 1.70 4/18/2010 Y - 33 1910300 50029221440000 NA 0.9 NA 6.80 4/12/2010 Y - 34A 1990040 50029221780100 NA 0.9 NA 5.10 4/11/2010 Y - 35A 2022370 50029221860100 NA 1.5 NA 10.20 4/15/2010 Y - 36 1 931 31 0 50029224000000 NA 0.9 NA 5.95 4/10/2010 Y -37A 2020460 50029224030100 NA 0.8 NA 6.00 4/14/2010 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFichc\CvrPgs _ Inserts\Microfilm _ Marker.doc Permitto Drill 2010430 DATA SUBMITTAL COMPLIANCE REPORT 8~25~2003 Well Name/No. PRUDHOE BAY UNIT Y-26A Operator BP EXPLORATION (ALASKA) INC ~lNo. 50-029-22191-01-00 MD 11822 .,./ 'I-VD 8988 .--- Completion Dat 8/17/2001 --" Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey ~ y,,(.,/t. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt y RS Reservoir Saturation · GR Gamma Ray (data taken from Logs Portion of Master Well Data Maint) Log Log Run Name Scale Media No Interval OH / Dataset Start Stop CH Received Number Comments 10682 11822 Open 1/11/2002 10521 10682 11822 Open 1/11/2002 10521 Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis ~'N'''~ R o.c.o, ivo. d ? Daily History Received? Formation Tops ~/N Transmittal Form Ir~/ BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Y-26A Prudhoe Bay Unit Contains the following: '. 1 LDWG format disk 1 listing 1 set films (3 films: GR MD, Resistivity MD and TVD) 1 set prints (3 prints: GR MD, Resistivity MD and TVD) ,,.,.........,,'.',,'.,',',..'.,,.,',...,,.....,.,., LAC:16369 Date: Jan 08,2002 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING OR FAXING YOUR COPY FAX: (403) 537-3767 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403) 537-3752 FAX: (403) 537-3767 ,,:?.:r,.~ 1i 2002 was Con& C,'otr~miSSior, ALASKA OIL AND GAS CONSERVATION COMMISSION 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-043 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22191-01 ~,, .~~-- -_ ~-_~ _ _~J _ 4. Location of well at surface ?'-~',~pL~:~,~,,~ ZOE.,~'I3ON~ 9. Unit or Lease Name 1472' SNL, 494' WEL, SEC. 33, T11N, R13E, UM i:~ "'~ '~'"'~~A'CE i ~ Prudhoe Bay Unit At top of productive interval 2546' SNL, 5148' WEL, SEC 33, T11N, R13E, UM At total depth~ x~,,¥E,~,~;~~. 10. Well Number Y-26A 3062' SNL, 597' WEL, SEC 32, T11N, R13E, UM "---- -~'~-- .... 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool KBE = 87.65' ADL 028288 12. Date Spudded 8,1, ,2001 110' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'8,, 5,2001 O,, 7,2001 115' Water depth' if °fish°re N/A MSL 116' N°' °f C°mpleti°ns One 17. Total Depth (MD.TVD) 118. Plug Back Depth (MD.TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 11822 8988 FTI 11822 8988 FTI [] Yes [] NoI (Nipple) 2094' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Surface 110' Cement to Surface 10-3/4" 45# L-80 Surface 2665' 13-1/2" 2925 cu ft Coldset III / II , 7-5/8" 29.7# NT95HS Surface 10667' 9-7/8" 1580 cu ft Class 'G' 5-1/2" 17# NT13FL4S 10398' 10667' 6-3/4" 168 cuft Class 'G' 3-ii~'.."x2-'7/8..' '" 9.3#xs.lS# 'L-80 10344' ' " 1i795' 3-3/4" Uncemented Slotted Liner .... 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Liner 4-1/2", 12.6#, 13Cr 10400' 10344' MD TVD MD TVD 10883' - 10947' 9004' - 9018' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 11046' - 11110' 9039' - 9053' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11306' - 11746' 9026' - 9008' 2000' Freeze Protect with MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) August 25, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO 8/31/2001 4 TEST PERIOD 170 613 691 89.67"I 3606 Row Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 25.8 28. CORE DATA ,, , ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit i SEP 1 001 Alaska Oil & Gas Cons. Commission ,Anchorage Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Sadlerochit 10902' 9008' 45N 11043' 9038' 45P 11058' 9042' Invert 45P 11610' 9039' Top of Sadlerochit 11762' 9003' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32.' I he're'b'y c(;rtiiY that the foregoing is tr'ue and correct to the best Of my knowledge ........ Signed TerrieHubb,e~.0)~.j~ ~ Title TechnicalAssistant Date ,~'/~"~/ Y-26A 191-090 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: Y-26 Common Well Name: Y-26A Spud Date: 8/7/2001 Event Name: REENTER+COMPLETE Start: 8/7/2001 End: 8/15/2001 Contractor Name: NABORS TRANSOCEAN Rig Release: 8/17/2001 Rig Name: CDR-1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations :8/7/2001 03:00 - 06:00 3.00 RIGU P PRE Rigging down off of Y-14B - scope and LD derrick. 06:00 - 10:00 4.00 RIGU P PRE RD berms, cords, and remainder of rig. Move off Y-14. 10:00 - 00:00 14.00 RIGU P PRE MIRU Y-26. !8/8/2001 00:00 - 01:00 1.00 RIGU P PRE RU on Y-26. Accept rig 0100 hrs 8/8/01. 01:00 - 03:00 2.00 BOPSUIq P DECOMP NU BOPE. 03:00 - 06:00 3.00 BOPSUI; P DECOMP Fill and body test stack. Pull BPV. Set TWC. 06:00 - 13:15 7.25 BOPSUR P DECOMP Perform BOP test. Witness waived by Lou Grimaldi. 13:15- 14:00 0.75 BOPSUF~ P DECOMP Prespud meeting. 14:00 - 15:00 1.00 BOPSUF~ P DECOMP Pull TWC. 15:00 - 16:00 1.00 KILL P DECOMP MU nozzle on 4' stinger. Level inj and stab pipe. 16:00 - 17:00 1.00 KILL P DECOMP Fill coil. Open master. WHP = 200 psi. IA = 720 psi. O^ = 0. 17:00 - 19:30 2.50 KILL P DECOMP RIH with BHA #1 circulating on choke. Minimal returns RIH to whipstock at 2.8 BPM. 19:30 - 20:15 0.75 KILL P DECOMP Tag whipstock pinchpoint. Correct depth (-10') to 10,668'. Establish loss rate. Bring on MP #1 to parallel with MP #2. 20:15 - 20:30 0.25 KILL N SFAL DECOMP Leak on MP #2 discharge at hammer union. Fix. 20:30 - 21:00 0.50 KILL P DECOMP Circulate above whipstock. Returns improving. 3.4/2.2/1050. SI backside. Injectivity at 2.0 BPM; 400 psi WHP and 1.0 BPM; 200 psi WHP. 21:00 - 21:30 0.50 PYA P DECOMP Safety meeting with cementers. 21:30 - 22:45 1.25 PYA P DECOMP RU cementers. Pull HP filter. Mix bio pill. PT lines to 4000 psi. 22:45 - 23:30 0.75 PYA P DECOMP Pump 13.8 ppg bentonite cement: 5 bbls neat, 10 bbls w/20 ppb aggregate, 5 bbls neat. Circulate cement to nozzle at 10566'. SI backside and downsqueeze cement past whipstock to perfs at 2.8/550. Started locking-up with neat at btm perf (aggregate at top perf). Continue squeezing 4 more bbls, open backside, and lay in remaining 10 bbls 1:1 to 10,100'. PUH. Squeeze to 1000 psi. Took one more bbl. Lost 300 psi in 15 minutes. Bump up again. Same leakoff. IA = 400; OA = 100. 23:30 - 00:00 0.50 PYA P DECOMP Open backside and prep to pump 1.5 ppb bio water to nozzle. 8/9/2001 00:00 - 01:30 1.50 PYA P DECOMP Wash excess cement from 10100'- 10656' with 1.5 ppb bio water. Repeat pass. 01:30 - 04:00 2.50 PYA P DECOMP POOH washing jewelry. 04:00 - 06:00 2.00 PYA P DECOMP L~D nozzle BHA. Wash stack and surface equip. 06:00 - 07:30 1.50 STWHIP P PROD1 MU milling BHA (diamond mill; SM). 07:30 - 10:00 2.50 STWHIP P PROD1 RIH to 3000'. Pressure well to 1000 psi. Minimal leakoff in 5 min. Continue RIH. Correct depth at flag (-22'). RIH and tag XN nipple at 10372'. Correct depth to 10384' (+12'). 10:00 - 12:00 2.00 STWHIP P PROD1 Mill XN 2.6/1450. Rough ride, numerous stalls. Milled past .10384', mill hard at 10386'. PUH. RIH. Clean past 10384', (~ontinue milling at 10386'. PUH. Had to work mill at 10384' again. Finally milled thru past 10386'. 12:00 - 12:30 0.50 STWHIP P PROD1 RIH. Tag and stall at 10662'. PU. Ease into it 2.711700. Start milling window here (ELMD pinch point is 10667'). Doesn't mill like cement. Good steady motor work at first, then grabby starting at 10663.5' -- tough establishing a pattern. 12:30 - 15:00 2.50 STWHIP P PROD1 Mill 0.5 ft to 10664' in two hours. Can't give it any weight w/o stalling. 15:00 - 17:45 2.75 STWHIP N i DPRB PROD1 POOH to check tools. 17:45 - 19:00 1.25 STWHIP N DPRB PROD1 LD BHA. Diamond mill beat-up. Diamonds gone from start of taper to 1/2" up gage. 3.67 OD here and 3.74" on gage above. String mill in-gage, but bunch of carbide broken out. Must have Printed: 8/21/2001 4:00:24 PM BP EXPLORATION Page 2 of 4 Operations Summa Report Legal Well Name: Y-26 Common Well Name: Y-26A Spud Date: 8/7/2001 Event Name: REENTER+COMPLETE Start: 8/7/2001 End: 8/15/2001 Contractor Name: NABORS TRANSOCEAN Rig Release: 8/17/2001 Rig Name: CDR-1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/9/2001 17:45 - 19:00 1.25 STWHIP N DPRB PROD1 done the damagae at the XN. 19:00 - 20:00 1.00 STWHIP N DPRB PROD1 MU BHA #3. Same set-up with new motor, DSM, SM. 20:00 - 22:30 2.50 STWHIP N DPRB PROD1 RIH. Correct depth at flag (-20'). RIH. Did not see XN. Continue in and tag 10661'. Did not correct depth again. PUH clean. Start time milling 10659'. Saw first motor work 10660.8'. and~ 22:30 - 00:00 1.50 STVVHIP P PROD1 Mill to 10662'. Looks much better. 8/10/2001 00:00 - 04:00 4.00 STVVHIP P PROD1 Mill window 2.7/1950 to 10668' with minimal WeB intially gradually increasing to 3000 # WeB. Stall at 10668'. Pumped 3 ppb bio sweeps. 04:00 - 05:00 1.00 STWHIP P PROD1 Mill formation to 10678'. 05:00 - 06:30 1.50 s'rWHIP P PROD1 Ream and backream window several times. Dry tag clean. Corrected window 10667' - 10674'; corrected TD 10684'. 06:30 - 08:00 1.50 STWHIP P PROD1 Take on Fie-Pro mud and swap well over. 08:00 - 11:00 3.00 STWHIP P PROD1 POOH. Add 6' to correct depth. Flag pipe. POOH. 11:00 - 12:00 1.00 STWHIP P PROD1 LD milling BHA. 12:00 - 14:00 2.00 DRILL P PROD1 Cut 45' of coil. Install weld-on connector. Pull and pressure test. 14:00 - 15:15 1.25 DRILL P PROD1 Pull BHI tools and shack together. 15:15 - 15:45 0.50 DRILL P PROD1 Safety meeting. 15:45 - 17:15 1.50 DRILL P PROD1 Test orienter. MU drilling BHA #4 (1.9 deg motor; M09) 17:15 - 18:00 0.75 DRILL P PROD1 RIH. Check tools at 600'. Getting no GR (this is a new probe). 18:00 - 23:30 5.50 DRILL N DFAL PROD1 POOH. Swap GR sub. RIH. Shallow test. POH retest at surface - okay. RIH to 600' retest - no GR response. POH, move GR back below survey sensor. 23:30 - 00:00 0.50 DRILL P PROD1 RIH, shallow test - okay. RIH to window. 8/11/2001 00:00 - 01:45 1.75 DRILL P PROD1 RIH. Correct depth at flag (-14') 01:45 - 03:45 2.00 DRILL P PROD1 Log tie-in. Not much there for GR character to tie into. Correct depth (-2'). 03:45 - 04:15 0.50 DRILL P PROD1 RIH. Tag 10660' (?). Orient highside to get thru window. 04:15 - 04:30 0.25 DRILL P PROD1 Run clean thru window. Tag TD 10682' 04:30 - 05:00 0.50 DRILL P PROD1 Orient to 20L. 05:00 - 09:00 4.00 DRILL P PROD1 Drill 20 - 50 FPH thru Shublik. GR crapped out. Drill to 10806. Getting more DL out of motor than expected in the Shublik. Need 18. Drilling 22 - 24. 09:00 - 09:30 0.50 DRILL P PROD1 Orient. Not getting 1:1. 09:30 - 11:15 1.75 DRILL N DFAL PROD1 Continue orienting. Took 35 clicks to get us there. 11:15 - 14:00 2.75 DRILL P PROD1 Drill 60L to 10800'. 14:00 - 17:45 3.75 DRILL P PROD1 POOH for planned motor change and resistivity. 17:45 -21:15 3.50 DRILL P PROD1 LD BHA #4. MU BHA #5 (USMPR; 1.0 deg motor; DS49) 21:15 - 23:15 2.00 DRILL P PROD1 RIH. Correct depth at flag ( -20 '). 23:15 - 00:00 0.75 DRILL P PROD1 MAD pass logging due to previous GR failures. 8/12/2001 00:00 - 01:00 1.00 DRILL P PROD1 Tie into gamma marker (+5'). 01:00 - 01:15 0.25 DRILL P PROD1 RIH and tag TD 10877'. 01:15 - 04:00 2.75 DRILL N DFAL PROD1 Mad pass to 10700'. 04:00 - 05:00 1.00 DRILL N WAIT PROD1 Relog from 10805' 05:00 - 05:15 0.25 DRILL P PROD1 Orient TF. 05:15 - 06:15 1.00 DRILL P PROD1 Drill to 10892'. TF flopped. 06:15 - 06:45 0.50 DRILL N DFAL PROD1 Re-orient -- not getting 1:1. Got to 45L 06:45 - 07:00 0.25 DRILL P PROD1 Drill to 10901, trying to get enough reactive to 105L. 07:00 - 09:00 2.00 DRILL N DFAL PROD1 Re-orient. Not getting any clicks. PUH to casing. Got a few here. RIH. Printed: 8/21/2001 4:00:24 PM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: Y-26 Common Well Name: Y-26A Spud Date: 8/7/2001 Event Name: REENTER+COMPLETE Start: 8/7/2001 End: 8/15/2001 Contractor Name: NABORS TRANSOCEAN Rig Release: 8/17/2001 Rig Name: CDR-1 Rig Number: Date From - To Hours Activity: Code NPT Phase Description of Operations 8/12/2001 09:00 - 12:30 3.50 DRILL P PROD1 Drill. Break at 10920', looks like we're into the Ivishak. Drill and orient to 11060'. 12:30 - 13:15 0.75 DRILL N STUC PROD1 PU to do wiper trip, but wouldn't come -- differentially stuck. Work pipe. Order crude. Let relax. Pull to 65k. Free 13:15 - 13:45 0.50 DRILL P PROD1 Wiper trip to window. 13:45 - 14:15 0.50 DRILL P PROD1 Orient 14:15 - 16:00 1.75 DRILL P PROD1 Drill. Off-bottom CTP increased by 500 psi. Eratic MWD signal. Still drilling. 16:00 - 16:30 0.50 DRILL N DFAL PROD1 Check HP filters -- clean. Drill to 11,155'. Lost all MWD signal. 16:30 - 20:30 4.00 DRILL N DFAL PROD1 POOH to check for plugged BHA. PJSM for new crew. 20:30 - 21:15 0.75 DRILL N DFAL PROD1 Chk tools, no bit jets plugged, motor functioned okay. Found sheared valve stem in bottom of orientator. 21:15 - 23:00 1.75 DRILL N DFAL PROD1 Download USMPR memory. USMPR quit responding to surf equip., unplug probe, reboot. Test - okay. 23:00 - 00:00 1.00 DRILL N DFAL PROD1 RIH, shallow test - okay. RIH. 8/13/2001 00:00 - 01:30 1.50 DRILL P PROD1 Continue RIH. Correct at flag (-33'). 01:30 - 03:00 1.50 DRILL P PROD1 Log tie-in. Correct depth (-27'). 03:00-03:30 0.50 DRILL P PROD1 RIH. SD at11020', 11100'. Tag TD11155' 03:30 - 04:15 0.75 DRILL P PROD1 Orient to 60L. Had 3 pressure spikes PUH. TF flopped. Re-orient, working shales. 04:15 - 06:00 1.75 DRILL P PROD1 Drill to 11240'. Sticky coming off bottom. 06:00 - 07:00 1.00 DRILL P PROD1 Wiper trip to window. 07:00 - 08:00 1.00 DRILL P PROD1 Drill to 11260' 08:00 - 08:15 0.25 DRILL N DFAL PROD1 Weak pulses, work pump, slam bottom, got em back. 08:15 - 09:00 0.75 DRILL P PROD1 Drill to 11300'. Not getting the pulses. 09:00 - 13:00 4.00 DRILL N DFAL PROD1 POOH. Pulled a little heavy thru window. Still something grabbin' us above whipstock 10650' - 10660'. 13:00 - 16:00 3.00 DRILL N DFAL PROD1 Change-out BHA. Swap pulser and battery pack. Test tools. 16:00 - 19:30 3.50 DRILL N DFAL PROD1 RIH. Test tool - ok. RIH. Tie-in to flag (-22'). GR coorelation = +2'. RIH and tag btm @ 11,302'. 19:30 - 20:00 0.50 DRILL N DFAL PROD1 Orient TF 60L. 20:00 - 21:00 1.00 DRILL P PROD1 Drill to 11,434' 21:00-21:15 0.25 DRILL P PROD1 Orient TF 60R. 21:15 - 00:00 2.75 DRILL P PROD1 Drill to 11,473'. 8/14/2001 00:00 - 00:30 0.50 DRILL P PROD1 Drill to 11,503. 00:30 - 01:45 1.25 DRILL P PROD1 ST to window - 10,700'. Tight spots at 11,250' and 11,160'. Back ream thru tire spots - okay. 01:45 - 02:15 0.50 DRILL P PROD1 Orient TF - 90R. 02:15 - 03:15 1.00 DRILL P PROD1 Drill to 11,533'. Lost pulse response. Work pumps. Stack on btm and unable to stall motor. 03:15 - 06:30 3.25 DRILL N DFAL PROD1 POOH to investigate BHA. 06:30 - 11:00 4.50 DRILL N DFAL PROD1 CO pulser. Motor OK. Bit 1-1. Some rubber on top of resistivity. Will break-down pulled pulser to check for rubber there. 11:00 - 11:45 0.75 DRILL N DFAL PROD1 RIH. Shallow test good. 11:45 - 12:45 1.00 DRILL P PROD1 Service inj chains. 12:45 - 16:30 3.75 DRILL N . DFAL PROD1 RIH. Make -18' corection at the flag. Attempt to tie-in w/GR, no tool response. 16:30 - 19:30 3.00 DRILL N .DFAL PROD1 POOH to inspect MWD. 19:30 - 20:30 1.00 DRILL N 'DFAL PROD1 Monitor well @ 500', R/B Injector. 20:30 - 00:00 3.50 DRILL P PROD1 Test MWD tools, found short to DAS-dir sensor, (SWWP). CIO stripping rubber. 8/15/2001 00:00 - 03:30 3.50 BOPSUR P PROD1 Test BOPE. Chk manifold, HCR - 250 / 3500 psi -okay. Test Printed: 8/21/2001 4:00:24 PM BP EXPLORATION Page 4 of 4 Operations Summa Report Legal Well Name: Y-26 Common Well Name: Y-26A Spud Date: 8/7/2001 Event Name: REENTER+COMPLETE Start: 8/7/2001 End: 8/15/2001 Contractor Name: NABORS TRANSOCEAN Rig Release: 8/17/2001 Rig Name: CDR-1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/15/2001 00:00 - 03:30 3.50 BOPSUF P PROD1 Annular, Pipe, Blind rams 250 / 3500 - okay. RU lub., pull TWC. 03:30 - 05:15 1.75 DRILL N DFAL PROD1 PU/MU BHA #9. 05:15 - 07:30 2.25 DRILL N DFAL PROD1 RIH to 500', sht MWD - okay. RIH. 07:30 - 07:45 0.25 DRILL N DFAL PROD1 Tie-in to EOP flag, make -29' correct. 07:45 - 08:00 0.25 DRILL N DFAL PROD1 Tie-in GR, +6' correct. 08:00 - 09:45 1.75 DRILL N DFAL PROD1 Cont. RIH, stack out wt at 10,763', 10,775', 11,011', 11,169'. PU, RIH and tag btm @ 11,533'. Orient TF 80L. 09:45 - 10:00 0.25 DRILL P PROD1 Drill to 11,553', orient TF to 90R. 10:00 - 11:00 1.00 DRILL P PROD1 Drill to 11,580', slowly. CIO FLO-PRO-2 mud system with new FLO-PRO-2 mud. (Used mud sent to Rig 3S, on "S" pad). 11:00- 12:30 1.50 DRILL P PROD1 Drill to 11,638'. 12:30 - 13:30 1.00 DRILL P PROD1 ST to window, RIH, clean to btm. 13:30 - 13:45 0.25 DRILL P PROD1 Orient TF - 90L. 13:45 - 16:45 3.00 DRILL P PROD1 Drill to 11,781'. 16:45 - 18:00 1.25 DRILL P PROD1 ST to window, chk survey. 18:00 - 18:30 0.50 DRILL P PROD1 Drill ahead, orient to 130-140R. 18:30 - 20:30 2.00 DRILL P PROD1 Drill to TD of 11,821'. Ratty drilling from 11,790' (Shublik?) 20:30 - 22:30 2.00 DRILL P PROD1 ST to window, relog up 10,750'-10,680' for missing data due to previous tool fail. 22:30 - 23:00 0.50 DRILL P PROD1 Tie-in GR, correct +4'. 23:00 - 23:45 0.75 DRILL P PROD1 Drift run to btm. Tag btm at 11,822'. 23:45 - 00:00 0.25 CASE P COMP POOH to run liner. 8/16/2001 00:00 - 03:00 3.00 CASE P COMP Cent POH to run liner. 03:00 - 04:30 1.50 CASE P COMP Monitor well ~ OK. Rack back injector. LD BHA. 04:30 - 06:30 2.00 CASE P COMP RU to run 2 7/8" & 3 1/2" slotted/solid liner. 06:30 - 08:30 2.00 CASE N WAIT COMP Wait on final log evaluation in Anch for placement of slotted liner in well. 08:30 - 08:45 0.25 CASE P COMP PJSM prior to picking up liner. BPX, NAD, Baker personnel. 08:45 - 13:45 5.00 CASE P COMP Run 2 7/8" slotted/solid liner and 3 1/2" solid liner. 13:45 - 14:00 0.25 CASE P COMP MU liner deployment tools. 14:00 - 14:30 0.50 CASE P COMP Rack out injector and MU connector to deployment tools. 14:30 - 17:30 3.00 CASE P COMP RIH with liner on CT - 90 fpm, 60 fpm below 9000'. Run in open hole okay, could not get past 11,795' (26' off bottom). 17:30 - 18:00 0.50 CASE P COMP Worked pipe, would not go deeper. 18:00 - 19:00 1.00 CASE P COMP Drop/pump ball. Release liner. Bottom at 11,795', slotted:l 1,306'-11,762', 11,047'-11,113', 10,884'-10,950'. TeL @ 10,344'. 19:00 - 23:15 4.25 CASE P COMP Displace FLO-PRO mud w/KCl. POOH, LD deployment sleeve, running equip. 23:15 - 00:00 0.75 CASE P COMP Run in holeto 2,000'. Spot methanol freeze protect. 8/17/2001 00:00 - 01:30 1.50 RIGD P POST POOH spotting methanol. 01:30 - 04:00 2.50 RIGD P POST RU N2 equip, PJSM, displace KCL from coil. 04:00 - 07:30 3.50 RIGD N WAIT POST Wait on DSM to set BPV. Clean pits and prep for move. 07:30 - 08:30 1.00 RIGD P POST RU lubricator and set BPV. RD. 08:30 - 10:00 1.50 RIGD P POST ND BOPs. 10:00 - 12:00 2.00 RIGD P POST Secure well, clean pits, secure coil and prep to move to ¥-30 well. RIG RELEASED: 1200 hrs, 8-17-2001. Printed: 8/21/2001 4:00:24 PM Obp ,. 't· BP Amoco Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco FleM: I:~'udhoe Bay Site: PB Y Pad Well: Y-26 Wellpn~: Y-26A Date: 916/2001 Tbae: 16:43:05 Page: 1 Co-erdtaate(NE) Reference: Well: Y-26, True North Vertical (1'I/!)) Reference: 38: 26 711011991 00:00 87.7 Section ('VS--') Reference: Well (0.00N,0.00E,253.55Azi) Survey Caltulation Metkod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Gee Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2001 Site: PB Y Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5948541.48 ft Latitude: 70 16 0.041 N 647748.73 ff Longitude: 148 48 18.991 W North Reference: True Grid Convergence: 1.12 deg Well: Y-26 Slot Name: 26 Y-26 Well Position: +N/-S 299.57 ft Northing: 5948773.85 ft Latitude: 70 16 2.980 N +E/-W-3420.10 ft Easting: 644323.66 ff Longitude: 148 49 58.540 W Position Uncertainty: 0.00 ft Wellpath: Y-26A Drilled From: Y-26 500292219101 ~Tie-on Depth: 10670.00 ft Current Datum: 38: 26 7/10/1991 00:00 Height 87.65 ft Above System Datum: Mean Sea Level Magnetic Data: 8/3/2001 Declination: 26.53 deg Field Strength: 57486 nT Mag Dip Angle: 80.76 dug Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 253.55 Survey: MWD Start Date: 8/15/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation , MD TVD: ' , 10670.00 8911.67 KO P 11822.00 8987.60 TD Survey MD ' Inel'' AZlm:'] TVD SSTVD N/S : E/W MapN,' MapE ,' : DLS VS deg.'.: dug ,: ff ff ff .. fi: ff. 'ff .. : degll00ff ft 10670.00 41.88 287.30 8911.67 8824.02 -1093.94 -4450.34 5947594.88 639895.45 0.00 4577.96 10690.00 46.60 287.00 8925.99 8838.34 -1089.82 -4463.68 5947598.74 639882.04 23.60 4589.58 10738.00 57.10 286.00 8955.60 8867.95 -1079.14 -4499.82 5947608.73 639845.70 21.94 4621.22 10767.00 64.00 284.90 8969.85 8882.20 -1072.43 -4524.15 5947614.97 639821.25 24.02 4642.65 10798.00 71.00 277.90 8981.72 8894.07 -1066.82 -4552.19 5947620.04 639793.11 30.73 4667.96 10838.00 75.20 269.10 8993.37 8905.72 -1064.52 -4590.34 5947621.61 639754.'92 23.52 4703.90 10877.00 77.10 258.90 9002.73 8915.08 -1068.48 -4627.94 5947616.93 639717.41 25.85 4741.08 10900.00 77.10 257.20 9007.86 8920.21 -1073.12 -4649.88 5947611.86 639695.57 7.20 4763.43 10940.00 77.10 252.60 9016.80 8929.15 -1083.28 -4687.51 5947600.99 639658.14 11.21 4802.40 · 10970.00 80.10 253.30 9022.72 8935.07 -1091.90 -4715.62 5947591.83 639630.20 10.26 4831.80 11009.00 77.20 250.80 9030.40 8942.75 -1103.68 -4751.99 5947579.36 639594.07 9.74 4870.02 11035.00 76,50 248.40 9036.32 8948.67 -1112.50 -4775.72 5947570.09 639570.51 9.38 4895.27 11057,00 76.90 244.50 9041.38 8953.73 -1121.05 -4795.34 5947561.16 639551,06 17.35 4916.51 11131,00 79.50 237.50 9056.53 8968.88 -1156.16 -4858.64 5947524.85 639488.45 9.90 4987.16 11164.00 82.20 235.70 9061.78 8974.13 -1174.10 -4885.84 5947506.39 639461.61 9.79 5018.32 11200.00 83.10 230.80 9066.38 8978.73 -1195.45 -4914.43 5947484.49 639433.43 13.73 5051.80 11269.00 88.60 226.90 9071.38 8983.73 -1240.72 -4966.22 5947438.25 639382.52 9.76 5114.28 11303.00 91.60 222.00 9071.32 8983.67 -1264.98 -4990.02 5947413.54 639359.20 16.90 5143.98 BP Amoco Baker Hughes INTEQ Survey Report INTEQ Compaay: BP Amoco Field: Prudhoe Bay Site: PB Y Pad Well: Y-26 Wellpath: Y-26A Bate: 916/2001 Time: 16:43:05 Page: 2 Co-ordlaate(NE) Reference: Well: Y-26, True North Vertical (TVD) Reference: 38: 26 711011991 00:00 87.7 Section (VS) Reference: Well (0.00N,0.00E,253.55Azi) Salwey Calcnlatlom Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD NIS E/W MapN MapE DLS VS ft deg deg fi: ff fi: fi: 11350.00 93.30 217.40 9069.31 8981.66 -1301.10 -5020.00 5947376.86 639329.91 10.43 5182.96 11382.00 94.75 219.90 9067.06 8979.41 -1326.02 -5039.94 5947351.55 639310.46 9.01 5209.14 11425.00 97.10 224.80 9062.62 8974.97 -1357.62 -5068.74 5947319.41 639282.27 12.58 5245.71 11471.00 97.90 230.10 9056.61 8968,96 -1388.45 -5102.32 5947287.94 639249,29 11.55 5286.65 11513.00 95.80 231.50 9051.60 8963.95 -1414.81 -5134.63 5947260.98 639217.49 6.00 5325.10 11542.00 95.80 232.60 9048.67 8961.02 -1432.55 -5157.38 5947242.80 639195.09 3.77 5351.94 11574.00 97.90 232.60 9044,86 8957.21 -1451.85 -5182.62 5947223.03 639170.22 6.56 5381.61 11618.00 101.00 228.30 9037.63 8949.98 -1479.47 -5216,08 5947194.77 639137.30 11.94 5421.53 11682.00 102.00 230.40 9028,86 8941.21 -1507,55 -5248,79 5947166.07 639105.14 5.20 5460.85 11722.00 106.10 234.00 9014.29 8926.64 -1543,23 -5294.75 5947129.52 639059.87 8.98 5515.03 11753.00 106,40 240.60 9005.60 8917.95 -1559.30 -5319.78 5947112.98 639035.16 20.46 5543.59 11781.00 104.80 244.90 8998.07 8910.42 -1571.64 -5343.75 5947100.18 639011.43 15.86 5570.07 11822.00 104.80 244.90 8987.60 8899.95 -1588.45 -5379.65 5947082.68 638975.87 0.00 5609.26 WELLpATH DETAIL~ y-26A Co~rdinate (N/E) Reference: Wel~ Centre: Y-25, True No~th Vertical (TVD) Reference: System: Mean Sea Leve~ Section (VS) Reference: S~ot 26 (0 00N,OOOE) Measured Depth Reierence: 38: 26 7/10/1991 0000 Calculation Method: Minimum Cu~ature ~8700 9000 9050 5650 5600-5550 55006450 540075350 5300~5250-5200 5150-5100 5050-5000 ~950~;900M850-4800 4750.4700-4650-4600 4550~:LSOO~450M4004350 430O 4350 44O0 4450 4500 4550 4600 4650 4700 4750 4800 485O 49O0 4950 5OOO 5O5O 5100 5t50 5200 52~0 5300 5350 5400 5450 5500 5550 5600 5650 5700 575O 58OO 585O 59OO 595O 6000 6O50 6100 6150 6200 9/6/2001 4;42 PM ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Prudhoe Bay Unit Y-26A BP Exploration (Alaska) Inc. Permit No: 201-043 Sur Loc: 1472' SNL, 494' WEL, SEC. 33, T1 IN, R13E, UM Btmhole Loc.3094' SNL, 651' WEL, SEC 32, T11N, R13E, UM Dear Mr. McCarty: Enclosed is the approved revised application for permit to re-drill the above referenced well. The revision is for a change in well name. BP originally intended to drill a multi-lateral well segment. Since the initial permit appliation, it has been decided to P&A the original wellbore and drill the planned segment as a sidetrack. Please note that the suffix on the API number has been changed to -.-0 l. The provisions of the original approved permit dated April 5, 2001 are in effect for this revision. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THI~.,COMMISSION Dated this ~ r*~_ of August, 2001 jjc/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~?-~' ~.,-"~" PERMIT TO DRILL Revised: 08106101, To S/T, No MultiLat 20 AAC 25.005 [] Drill [] Reddll 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 87.65' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 O~- ~'~s"tADL 028288 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1472' SNL, 494' WEL, SEC. 33, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 2542' SNL, 5029' WEL, SEC 33, T11N, R13E, UM Y-26A Number 2S100302630-277 At total depth ~,~KJ,4 ~1. Approximate spud date 3094' SNL, 651' WEL, SEC 32, T11N, R13E, UM~/~, I~c~ [C)~==,(0\~ Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028287, 651' MDI No Close Approach 2560 11925' MD / 8915' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10670' MD Maximum Hole Angle 90" Maximum surface 2076 psig, At total depth (TVD) 8800' / 3132 psig 18. Casing Program Specifications Setting Depth Size T(,D I~QttQrP Qvantitv of Cement Hole Casinq Weiqht Grade Couplinq Lenqth MD TVD MD TVD (include staqe data) 3-3/4" 3-1/2, x2-7/8,, 9.3~x6.16# L-80 ST-L 1545' 10380' 8694' 11925' 8915' Uncemented Slotted Liner 19. To be completed for aedrill, Re-entry, and Deepen Operations. AU G 0 6 ~ 0'01 Present well condition summary Total depth: measured 11087 feet Plugs (measured) true vertical 9222 feet Alaska 0il & Gas Cons. Commission Effective depth: measured 11002 feet Junk (measured) Anchorage true vertical 9159 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" Cemented 110' 110' Surface 2665' 10-3/4" 2925 cuft Coldset III & II 2665' 2665' Intermediate Production 10669' 7-5/8" 1580 cuft Class 'G' 10669' 8911' Liner 689' 5-1/2" 168 cuft Class 'G' 10398'- 11087' 8708' - 9222' Perforation depth: measured 10662'- 10682', 10716'- 10746', 10800'- 10870' true vertical 8906' - 8921', 8946' - 8968', 9008' - 9060' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot r'l Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact £ng/neer Name/Number: Thomas McC. arty, 564-5697' Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the. for..e~..q.~ing is true and correct to th'e best of my knowledge ,,~ /.. / Signed Thomas McCarty ~r, ,~~/~/ ~'~ Title CT Drilling Engineer Date Permi~ N'_umb~r "'I'AP~ Number .............. I "' ~l:~proval Date I See cover letter ~ ~ 2o,/-,~:::~ 4/,.._~ 1 50- 029-22191-01 I ~' ~-0 I I for other requirements Conditions of Approval: Samples Required I"1 Yes '~ No Mud Log Required [] Yes ~ No Hydrogen Sulfide Measures [] Yes "~ No Directional Survey Required "~ Yes [] No Required Working Pressure for BOPE r"12K 1"i3K []4K []5K I-IIOK []15K 'l~3.5KpsiforCTU Other: ORI(~INAL 81GHED BY by order of ..Approved By ,-...... J M ~l,:,me,~r, Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX Y-26 Sidetrack Summary of Operations: Y-26 currently produces 50bbls/d @ 80% watercut. In order to increase productivity a sidetrack, (Y-261L~) to the southwest will be drilled, crosscutting zone 4 to access bypassed oil in zone 4B. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Set whipstock. Completed on August 5, 2001 Drift well with dummy whipstock. Integrity test IA after displacing to seawater & installing dummy gas lift valves. Set whipstock using e-line at 10666' Phase 2: P&A existing perforations, mill window, drill and complete sidetrack. Planned to begin Aug 8, 2001. The existing perforations will be P&A'd with cement and a 3.8" window will be milled off the whipstock with Nabors CDR1. 2~A'' coil will be used to drill a 1260 feet, 3~A'' OH sidetrack, (as per attached plan) and run a solid / slotted 2~A'' x 3¥2" liner completion. The liner will remain un-cemented. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8", 6.16#, L-80, X-over to 3V2, 9.3#, L-80 solid & slotted liner be run from 10,380'(TOL) to TD. Liner to remain un-cemented. The 3V2 liner will be placed from the TOL down to approx, two joints outside the window. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log with resistivity will be run over the open hole section. · A MCNL will be run in the cased hole Hazards H2S was measured at 20 ppm on Sep 16, 2000. The well-path will cross 2 faults. Experience with the first fault makes for a low risk of lost circulation. The second fault is likely to be more dilated and making the risk of lost circulation higher. Reservoir Pressure Res. press, is estimated to be 3132 psi at 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2076 psi. TREE: 4 1/16"- 5M CIW WELLHEAD: 11" - 5M FMC ACTUATOR: BAKER (~-26A Proposed Completion KB. ELEV = 87.65' BF. ELEV = 51.11' SSSV LANDING NIPPLE I 2094'1 (OTIS "HXO")(3.813" ID) CMT'd lO 3/4", 45.5#/ft, I 2665'1 NT-80 BTRS KOP: 2950' MAX ANGLE: 49° @ 5527' GAS LIFT MANDRELS CAMCO "KBMG" (w/1" BK LATCH) N-° MD(BKBI TVDss DEV. 6 2986' 2898' 3° 5 5496' 5004' 49° 4 7494' 6424' 43° 3 8818' 7409' 39° 2 9701' 8094' 41 ° 1 10,310' 8581' 41° 4 1/2", 12.6#/ft, 13CR, TDS CHROME TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT 5 1/2" LINER 7 5/8", 29.7#/ft, NT-95HS NSCC I 10,669'I 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) I 10,337'I Right-hand release latch (BAKER K-22) I 10,343'I 7 5/8" BAKER PACKER I 10,344'I ( SABL-3, 4.00" I.D.) 4 1/2", 12.6#/ft, 13Cr TAILPIPE 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWN" NIPPLE (PARKER) (3.725" ID) ELMD 4 1/2" WLEG 10,366' 10,387' 10,384' 10,400' whipstock at approx. 10,660'. PERFORATION SUMMARY REF LOG: ATLAS - BHCA 7-24-91 TIE-IN LOG: SWS - CBT 8-16-91 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8" 6 10,662- 10,682' OPEN/2-8-96 3 3/8" 6 10,716- 10,746' 3PEN/2-8-96 3 3/8" 6 10,800 - 10,870' DPEN/8-18-91 CHROME TBG & LINER PBTD ~ 5 1/2", 17 #/ft, 13Cr, FL4S I I 1,087' I .0232 BBL/FT Combo solid and cemented 2 7/8" x 3-1/2" liner, uncemented Perfs P&A'd with cement TREE= 4-i/16" - 5M CIW WI~_LHEAD= 11"-5M FMC '~'i:5~6i~:: ................. 'i~'i~;"i~'~'": ............................. '~¢: ~: ~x Angle = 49 ~ 5527 Datum ~D= 10-3/4" CSG, 45.5#, NT80, .0961 bpf, ID=9.953 Id 2665' Minimum ID = 3.725" @ 10387' 4-1/2" PKR 'SWN' NIPPLE I 4-1/2" TBG, 12.6#, 13Cr, .0152 bpf, ID=3.958 10344' ITOPOF 5-1/2" LNR Id I 4-1/2" Tailpipe, 12.6#, 13Cr, .0152 bpf, ID=3.958 Id 10398' 10400' J 7-5/8" LNR, 29.7#, NT95HS, .0459 bpf, ID=6.875 Jd 10669' PERFORATION SUMMARY REF LOG: ATLAS-BHCA, 7/24/91 ANGL~'¥'~:'~5'"'~'~'i ........... I-'? @ ? Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 10662-10682 O 2/8/96 3-3/8 6 10716-10746 O 2/8/96 3-3/8 6 10800-10870 O 8/18/91 I F'BTDH 11002'I 11087' 5-1/2" LNR, 17#, 13Cr, .0232 bpf, ID=4.892 Id Y-26 b SAFETY NOTES 2094' [dOTIS HXO SSSV LANDING NIP, I93.813 I GAS LIFT MANDRELS I STAI MD I TVD I BEV TYPE MAN 6 I 29861 28981 31 CAMCO 5 I 54961 50041 491 CAMCO 4 I 7494 I 6424 I 431 CAMCO 3 I 88~81 74°91 391 CAMCO 2 I 9701180941 41] CAMCO ~ 1103101 8581I 4~I CAMCO BK BK BK BK 10337' Id4-1/2" PKRSWS NIP, ID=3.813 I I 10343' HBKRK22RightHandRe,easeLatch 10344' H7-s/8"x 4-1/2" BKRPKR, 19=4.00 10366' Id4-1/2" PKRSWS NIP, 19=3.813 I I 10384' I-I I 10387' H4-1/2,, PKRSWNNIP, ID=3.725 I 10400' H4-~/2"WLEG I DATE REV BY COMMENTS 07/30/91 MJL ORIGINAL COMPLETION 01/07/01 SIS-SLT CONVERTED TO CANVAS PRUDHOE BAY UNIT WELL: Y-26 PERMIT No: 191-0900 APl No: 50-029-22191 Sec. 34, T11 N, RG13E BP Exploration (Alaska) I -6,000 Y-26 I I I -5,500 -5,000 -4,500 JY-26L1 Possible faults 1 & 2 are numbered -500 _ -1,000 -1,500 -2,000 X distance from Sfc Loc -2,500 0 -4,~ O0 IWell Name Y':~" I CLOSURE IDistance 6,670 ff Az 282 deg NEW HOLE E/W (X) NIS (Y) Kick Off -4,429 -1,179 ,,, ,, , TD -5t401 -1 w724 State Plane 638~922 5~947t050 Surface Loc 644,324 5,948,774 DLS degll00 Tool Face Length Curve I ' 6 0 ~0 , , Curve 2 18 -18 235 ~Curve 3 18 -90 335 , , Curve 4 18 0 69 Curve 5 12 90 289 , Curve $ 12 -90 299 1,257 Drawn: 6/1/00 17:09 Plan Name: Case 101 IY-26 Vertical Section Path Distance (Feet) 0 500 1,000 1,500 2,000 2,500 ~oo 1' 0~00 ~ Marker Depths {~Orlg Wellborn TSAG ~fl: TVD TSHU HOT8984 I 8,9841ft TVD TS^D I S,S~SI~ ,TVD , Kick Off 8,82~41ff TVD 10,6701ff MD IDeprtr (~KO 4r$98 ff ~ ~°,~7°1 IMD New HOle 1255I I Total MD 11~925I ] TVD TO , 8,9!Sl DLS deql100 Tool Face Length Curve 1 ' 6 0 ~30 Curve 2 18 -18 235 Curve 3 18 -90 335 Curve 4 18 0 69 , ,, Curve 5 12 90 289 , Curve 6 12 -90 299 , , ,, 1,257 Drawn: 6/1/00 17:09 Plan Name: Case 101 m CDR1 Drilling Wellhead D(" ,il 16 19.30' 21.10' Rig Floor ~ CT Injector Head Otis Q.C. thread half Traveling plate 5.59' ~0'~ Dual '1 5-1/2" lubricator Jacking Frame Top Stationary Plate Annular BOP (Hydril),7-1/16" ID Annular BOP (Hydril),7-1/16" ID Top blind ! shearI 2-7/8" - 3.5" Variable bore rams Kill Line T.O.T. 5,000 psi W.P. L R_%[n Type Dual Gate BOPE I Top 2 3/8" pipe / slipsI I Btm 2 7/8" pipe / slips Manual Master Valve -- Tubing Hanger 9-5/8" Annulus 0.66' , IIIIIIIIIIIIIIIIIIIIIIIIIIIIIII Rig Matt Ground Level 13-3/8" Annulus ALASKA OIL AND GAS CONSERVATION COMMISSION Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re'. Prudhoe Bay Unit Y-26L 1 BP Exploration (Alaska) Inc. Permit No: 201-043 Sur Loc: 1472' SNL, 494' WEL, SEC. 33, TllN, R13E, UM Btmhole Loc.3094' SNL, 651' WEL, SEC 32, T1 IN, R13E, UM TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dear Mr. Sherwood: Enclosed is the approved application for permit to drill the above referenced Well. The permit to drill does not exempt yOu from obtaining additional permits required by law frOm other governmental agencies, and does not authorize conducting drilling operations until all Other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC25 036. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by Contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 5' ~-~ day of April, 2001 j jo/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS( OILAND GAS CONSERVATION CCi" .ISSION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Ddll [] Redrill lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) :10. Field and Pool BP Exploration (Alaska) Inc. KBE = 87.65' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 o ~z.~7~' ADL 028288 4. Location of well at surface 7. Unit or Pr~'erty Name 11. Type Bond (See 20 AAC 25.025) ,1472' SNL, 494' WEL, SEC. 33, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number . 2542' SNL, 5029' WEL, SEC 33, T11N, R13E, UM Y-26L1 Number 2S100302630-277 At total depth 9. Approximate spud date 3094' SNL, 651' WEL, SEC 32, T11N, R13E, UM 03/08/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028287, 651' MDI No Close Approach 2560 11925' MD / 8915' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10670' MD Maximum Hole Angle 90 o Maximum surface 2076 psig, At total depth ('rVD) 8800'/3132 psig 18. Casing Program Specifications Setting Depth Size Top , Bottom ,, Quantity of Cement Hole Casing Weight ...Grade Coupling Length MD TVD ., M,D TVD (include sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 1545' 10380' 8694' 11925' 8915' Uncemented Slotted Liner , , ,,..CE!VED ,,,, 19. To be completed for Redrill, Re-entry, and Deepen Operations. F E B Present well condition summary Total depth: measured 11087 feet Plugs (measured) Alaska 0il & Gas Cons. Commission true vertical 9222 feet Anchorage Effective depth: measured 11002 feet Junk (measured) true vertical 9159 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" Cemented 110' 110' Surface 2665' 10-3/4" 2925 cu ft Coldset III & II 2665' 2665' Intermediate Production 10669' 7-5/8" 1580 cuft Class 'G' 10669' 8911' Liner 689' 5-1/2" 168 cuft Class 'G' 10398' - 11087' 8708' - 9222' Perforation depth: measured 10662' - 10682', 10716' - 10746', 10800' - 10870' true vertical 8906' - 8921', 8946' - 8968', 9008' - 9060' 20. Attachments ~11 Filing Fie ' ' [] Property Plat ~ BOP Sketch [] Diverter Sketch [] Drilling Program ....... [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer'Name/Number: Alistair Sherwood, 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 ,, 21. I hereby certify that the foreli(~in~is,, true and correct,to the best of my knowledge Signed Alistair Sherwood ~/~¢~///~¢~ Title CT Drilling Engineer Date 0~'//Cf/e [ · ~ ~ ~.~ . .... ~... (,.:.., · ..... I .'::" ": ':.." ": ':" "::;":::' .: :'".:':.':". :,.':.":': ':: ::,": ~',: '."?:.':"':' ;:~i"':'.:: ' "' :' .'.? :..':': '~''' .: .' :': ;~ ."i '":: i.' ,:,.',CommtsslO,rll:.,;Uie~,,O~l~,: .:::.: ..,.,. :...: ~:.. ,,:,:.,.,.:,,:: ~.,,: · Permit NN~lmber 1AP, Number I 2//~D~e Isee c°ver'etter 19...1.,.09'b .2-O/-O r.,/.~ 50-029-22191-60 . ~/ ~ for other requirements .... '~'onditions of ApProval: Samples Required [] Yes [] No Mud Log Hequired [] Yes [] No Hydrogen Sulfide Measures I~ Yes [] No Directional Survey Required I~ Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~J~3.5K psi for CTU Other: ' '. "', by order of I Approved By D Taylor ,,.%,',e:,~rnol~n'i Commissioner the commission Date Form 10-401 Rev. 12-01-85 OR1G,,t,:AL Submit It Iicate bp February 14, 2001 To: Attention: Subject: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Tom Maunder Petroleum Engineer Well Y-26 CTD Sidetrack Prep BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well Y-26 is scheduled for a through tubing lateral to be drilled with coiled tubing. The following summarizes the procedure required to prep Y-26 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. :t. Tree wing & master valves successfully tested on 12/31/00. 2. Tubing & inner annulus packoff seals were successfully pressure tested on 12/31/00. 3. Using slickline, tbg will be drifted and caliper run. Caliper will assess 5.Y2" liner integrity at proposed whipstock setting depth. 4. Using slickline, gas lift mandrels will be dummied & IA liquid filled prior to pressure testing same. 5. Using wireline a flow through whipstock will be run, oriented & set at approx 6. Service coil may then mill the casing window into the zone 4 reservoir. Slickline, wireline & service coil prep work is expected to commence Feb 25th. Coil tubing drilling operations, as detailed below will commence Feb 28th, 2001. 1. A 3.3A'' sidetrack, -1250' long will be drilled out of casing into the zone 4 reservoir. 2. The sidetrack will be completed with a 2.7/8, solid & perforated liner combination, un-cemented in order to continue producing from the original wellbore. Alistair Sherwood CT Drilling Engineer Tel: 564-4378 Fax: 564-5510 Cell: 440-8301 sherwooa@bp.com RECEIVED FEB ~ 0 70~1 Alaska 0il & Gas Cons, Commission Anchorage Well File Petrotechnical Data Center Terrie Hubble BPX Y-26 Sidetrack Summary of Operations: Y-26 currently produces 50bbls/d @ 80% watercut. In order to increase productivity a sidetrack, (Y-26L1) to the southwest will be drilled, crosscutting zone 4 to access bypassed oil in zone 4B. By using a flow through whipstock to initiate the sidetrack and an un-cemented completion of solid & perforated pipe, a percentage of post sidetrack production should be retained from the original wellbore. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus, (IA). Set whipstock. Mill window if service coil available. Planned for Mar. 8-10, 2001 · Drift well with dummy whipstock. · Integrity test IA after displacing to seawater & installing dummy gas lift valves. · Set flow through whipstock using e-line at approx. 10660' · Mill casing window with service coil if available. Phase 2: Drill and Complete sidetrack: Planned for Mar 13, 2001 2.3/8" coil will be used to drill a 1260 feet, 3.3,4'' sidetrack, (as per attached plan) and run a solid / slotted 2.7/8" liner completion. The liner will remain un-cemented in order to preserve production from the existing wellbore. Mud Program: · Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.6 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. RECEIVED FEB 2 0 001 Alaska Oil & Gas Cons. Commission Anchorage Casing Program: · 2 7/8", 6.16#, L-80, solid & slotted liner be run from 10,380' to TD. Liner to remain un-cemented. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray log will be run over the open hole section. · A real time resistivity log will be run while drilling. Hazards H2S was measured at 20 ppm on Sep 16, 2000. The well-path will cross 2 faults. Experience with the first fault makes for a Iow risk of lost circulation. The second fault is likely to be more dilated and making the risk of lost circulation higher. Reservoir Pressure Res. press, is estimated to be 3132 psi at 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2076 psi. ' TREE='4-1/16"- 5MCIW WELLHEAD= 11"-5M FMC ~ A (;TUA-FOR= BAi;(ER kBi EL~'= 87'i'~S1 KOP= 2950' Max Angle = 49 @ 5527 Datum TV D= I I 10-3/4" CSG, 45.5#, NT80, .0961 bpf, ID=9.953 I--~ 2665' IMinimum ID = 3.725" @ 10387' 4-1/2" PKR 'SWN' NIPPLE I 4-1/2" TBG, 12.6#, 13Cr, .0152 bpf, ID=3.958 10344' ITOPOF 5-1/2" LNR Id I 4-1/2" Tailpipe, 12.6#, 13Cr, .0152 bpf, ID=3.958 Id 10398' 10400' 7-5/8" LNR, 29.7#, NT95HS, .0459 bpf, ID=6.875 Id 10669' ~ PERFORATION SUMMARY REF LOG: ATLAS-BHCA, 7/24/91 ANGLE AT TOP PERF: I~.? @ 9. Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8 6 10662-10682 O 2/8/96 3-3/8 6 10716-10746 O 2/8/96 3-3/8 6 10800-10870 O 8/18/91 I ~Dl-I I 5-1/2" LNR, 17#, 13Cr, .0232 bpf, ID=4.892 Id 11002' I 11087' I Y-26 L I SAFETY NOTES I 2094' I--lOTS HXO SSSV LANDING NIP, ID3.813 I I I/ I GAS LIFT MANDRELS I 29861 2898] ~1 c~uco..H I s"~61 s°°"l ~91 CAUCO I BK I I Z~I ~2~1 ~1 CAUCO] BK I I ~8~Sl 7~°~1 ~91 CAUCO BK 19~0~1S09.1 ~1 C~UCO~K 1103401 8581I 411 CAMCO BK ~~ 10337' J 10343' 10344' Id4-1/2" PKRSWS NIP, ID=-3.813 I Jd BKR K22 Right Hand Release Latch Id7-5/8" x 4-1/2" BKR PKR, ID=4.00 J 10366' H4-1/2,, PKRSWS NIP, ID=3.813 ] 10384' Id ~-M~I 10387' H4-1/2. PKRSWNNIP, ID=-3.725 J 10400' H4-1/2"WLEGI RECEIVED FEB % 0 2001 Alaska 0il & Gas Cons. Commission Anchorage DATE REV BY COMMENTS 07/30/91 MJL ORIGINAL COMPLETION 01/07/01 SlS-SLT CONVERTEDTO CANVAS PRUDHOE BAY UNr]' WELL: Y-26 PERMIT No: 191-0900 APl No: 50-029-22191 Sec. 34, T11 N, RG13E BP Exploration (Alaska) TREE: 4 1/16"-5M CIW i" "-26L1 Proposed Completio{ WELLHEAD: 11" - 5M FMC , ACTUATOR: BAKER KB. ELEV = 87.65' BF. ELEV = 51.11' SSSV LANDING NIPPLE [ 2094'I (OTIS "HXO")(3.813" ID) CMT'd 10 3/4", 45.5#/ft, 2665,~ NT-80 BTRS I I KOP: 2950' MAX ANGLE: 49© @ 5527' GAS LIFT MANDRELS CAMCO "KBMG" (w/1" BE LATCH) N° MD(BKB) TVDss DEV. 6 2986' 2898' 3° 5 5496' 5004' 49° 4 7494' 6424' 43° 3 8818' 7409' 39° 2 9701' 8094' 41° 1 10,310' 8581' 41° 4 1/2", 12.6#/ft, 13CR, TDS CHROME TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT & ~,'..'~s Cons. Commissiotl kr~chorage TOP OF mIw ,10,398 5 1/2" LINER 7 5/8", 29.7#/ft, I 10,669'I NT-95HS NSCC 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 0,3371 Right-hand release latch I 10,343' (BAKER K-22) , .... 7 5/8" BAKER PACKER I 10,3441 ( SABL-3, 4.00" I.D.) 4 1/2", 12,6#/ft, 13Cr TAILPIPE 4 1/2 .... SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 .... SWN" NIPPLE (PARKER) (3.725" ID) ELMD 4 1/2" WLEG 10,366' 10,387' 10,384' 10,400' Flow-through whipstock at approx. 10,660'. PERFORATION SUMMARY REF LOG: ATLAS - BHCA 7-24-91 TIE-IN LOG: SWS - CBT 8-16-91 IpPEN/SQZ'D EN/2-8-96 PEN/2-8-96 PEN/8-18-91 CHROME TBG & LINER PBTD ~ 5 1/2", 17 #/ft, 13Cr, FL4S I 11,087'1-- .0232 BBL/FT Combo solid and 3~.e~~~' 2 7/8" liner, uncemented '>..,.-',.:'.',i',"=:,..,.'. ; ,'.'>:-"~ "Y"".. ~:~ i . ' .~.;...' '. '-, 'i ~:i;i'.', '".'i '"..,.-.- '"?". ""'"":' "-. · · - .";' %/: ':/'!:'" "' "'. ~:· ~' ,,~" ""'":'".· '" · . ...."'=.i.;.."/..'.:'.~;.,?~':...'.'..-..".-. . · :.. ,?..'. '.=.:,.":'.'~..'::!... !~, ..,..'..... ,. . ... I -6,000 Y-26 I I I -5,500 -5,000 -4,500 IY-26L1 Possible faults 1 & 2 are numbered -500 -2,000 X distance from Sfc Loc -2,500 0 -4j DO IWell Name Y-26 I CLOSURE r Distance 5,670 ft I Az 252 deg NEW HOLE E/W (X) N/S (Y) Kick Off -4,429 -1,179 TD -5,401 -1,724 State Plane 638,922 5,947,050 Surface Loc 644,324 5,948,774 DLS degl100 Tool Face Len~lth Curve 1 ' 6 0 ~0 Curve 2 18 -18 235 Curve 3 18 -90 335 Curve 4 18 0 69 Curve 5 12 90 289 Curve 6 12 -90 299 1,257 Drawn: 6/1/00 17:09 Plan Name: Case 101 Y-26 Vertical Section 87OO 8750 8800 8850 8900 8950 9O00 905O 9100 0 500 -.8,915 - -HOT8984 Path Distance (Feet) 1,000 1,500 2,000 2,500 I I I Angle (~ K.O.= 42 deg MD:10670 Tot Drld:1255 ff 11925 TD Marker Depths ~DOrig Wellbore TS^ I TSHU J 8,835Jff 'I'VD HOT8984 I 8,ga41f TVD TS^D [ 8,9'tgLf'rvD IKickOffI 8,8241fTVD 10,670 Iff MD IDeprtr (~KO 4,598 ff IMD KO Pt lO,67oI MD New Hole 1255I I Total MD 11,925I TVD TD 8,9151 DLS de~/100 Tool Face Lenl~th Curve 1 ' 6 0 ~30 Curve 2 18 -18 235 Curve 3 18 -90 335 Curve 4 18 0 69 Curve 5 12 90 289 Curve 6 t2 -90 299 1,257 Drawn: 6/1/00 17:09 Plan Name: Case 101 CDR1 Drilling Wellhead{,r3etail Y-26L1 16. 19.30' 21.10' Rig Floor 5.59' ~o'~ 65' Dual T.O.T. 5,000 psi W.P. Ra~ Type Dual Gate BOPE ~ CT Injector Head Otis Q.C. thread half Traveling plate 5-1/2" lubricator Jacking Frame 4----Top Stationary Plate Annular BOP (Hydril),7-1/16" ID Annular BOP (Hydril),7-1/16" ID Top blind / shearI Bottom 2 3/8" Variable pipes Kill Line .------ I Top 2 7/8" pipe / slips Btm 2 3/8" pipe / slips Manual Master Valve Tubing Hanger 9-5/8" Annulus 0.66' L Ground Level 13-3/8" Annulus At,~ska 0il & Gas Cons. Commission,, .,, -I 3..80965 DATE I CHECK NO. ] 12/28/00 I 00:[809651 VENDOR ^L^SKAO I LA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 122100 CK122100E 100.00 100.00 PYMT :OMMENTS: PeVnit To Drill --ee HANDL[N~ INST: S/H'- Te~eie Hub31e X46~8 E AWACHED CHECK IS IN PAYMENT FOR ITEMS DE~;RIBED ABOVE. ~1~1 ~e]~ ~1'~_1~ 1 O0. o0 I OO :!:;"::!:!' :..; ;'::" 'N;;;~t~N:~,'.'''''Ci~'';r..::4':~, :.':: ..: ! :::::::::::::::::::::: C;.~'VF. ,'.'~O ;.', '.:'. ,:]' : 'i'. !;..!:i.: "':;;'::'-: ~-389 412 'T~':':~".T:h.~;:¢ ..,:.:;".ALASKA OIL AND OAS::.:::.. ? ' 'm~I :i:':'.6~':!i:i':.':i .... :':::; :~!.:33~' '.i~:EST 7TH:;.~?~E~U~:;;;:/ ~.U . . . . .. :.':' ...;; ::..:~: .... .... :............,...::.; $1 oo: oo,J NOT:'!~LID AFTER. 120 DAYS..:..:'. ~~'.~::,~ I :: i.;:l°o '"::::, :"::.'.' ... ANCHORAOE A'K ·99501 WELL PERMIT CHECKLIST FIELD & POOL _~' y~;),/.~'"',~ ADMINISTRATION INIT CLASS .._.~ ~,., ENGINEERING GEOLOGY 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can-be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided .................... Y N 15. Surface casing protects all known USDWs... ........ Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg. ' Y N 18. CMT will cover all known productive horizons. ~ Y N 19. Casing' designs adequate for C, T, B & permafrost ....... Y' N 20. Adequate tankage or reserve pit ................. Y N 21. If a re-drill, has a 10-403 for abandonment been approved... (~ N 22. Adequate wellbore separation proposed .............. Y N 23. If diverter required, does it meet regulations .......... Y N 24. Drilling.fluid program schematic & equip list adequate ..... Y N 25. BOPEs, do they meet regulation ................ Y N 26. BOPE press rating appropriate; test to psig. Y N 27. Choke manifold complies w/APl RP-53 (May 84) ......... Y N 28. Work will occur without operation shutdown ........... Y N 29. Is presence of H2S gas probable ................. Y N N .,/ WELL NAME _y--.~__~// PROGRAM: exp dev ~ reddl ,/serv wellbore seg ann. disposal para req GEOL~,AR~A ~>~:, UNIT# ~~ ... ON/OFF SHORE 30. Permit can be issued wlo hydrogen sulfide measures ...... Y 31.' Data presented on potential overpressure zones ...... . 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress reports [exploratory o/q~] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ..... . . APPR DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; " (C) will not impair mechanical integrity of the well used for diSposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. , ,, GEOLOGY: Y N Y N Y N Y N Y N ENGINEERING:. ' UlC/~rm. ular COMMISSION: JMH ,-, Comments/Instructions: O Z O c:Vnsoffice\wordia n~diana~checklist (rev. 111011100) '/' redrll ;/ WELL PERMIT CHECKLIST COMPANY ~;) ' WELL NAME FIELD & POOL ~.* (--//~/"._~'~ INIT CLASS ~L,/ / (~//-__~ ADMINISTRATION PROGRAM: exp dev~ GEOL AREA ~"_'~-'"'~ A/~P~R DATE , 1. Permit fee attached.--,E-. 2. Lease number appropfi~,t;. 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate weilbore separation proposed ............. ~ serv~ wellbore seg ann. disposal para req UNIT# (~ f/~~1~ ON/OFF SHORE 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ....... ~ ........ 26. BOPE press rating appropriate; test to ~)~ psig. 27. Choke manifold complies w/APl RP,53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... A~P~ DATE / 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ........... fi...~/u, . .y. ,N, 34. Contact name/phone for weekly progress reports [explo.~.afory omyj ¥ ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause ddlling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: Ul~nnular WM~---....~ COMMISSION: · j M,~--~¢~-,~~ Comments/Instructions: 0 0 Z 0 c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this , nature is accumulated at the end of the file under APPENDIXi No 'special'effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 02/01/08 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 02/01/08 192557 01 3.125" USMPR *** LIS COMMENT RECORD RECEIVED ,:,;:1i 2002 Alaska Oil & Gas Cons.,~ · ' ' Anchorage Remark File Version 1.000 Extract File: ldwg.las ~Version Information VERS. 1.20: WRAP. NO: ~Well Information Block ~MNEM.UNIT Data Type STRT.FT 10449.0000: STOP.FT 11822.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM. UNIT SECT. TOWN N RANG PDAT EPD F LMF FAPD F DMF EKB F EDF F EGL F CASE F OS1 ~Remarks (1 CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ............................... Starting Depth Ending Depth Level Spacing Absent Value BP Exploration Inc. Y-26A Prudhoe Bay Unit 1472' SNL, 492' WEL North Slope Alaska Baker Hughes INTEQ 3.125" USMPR 16-Aug-01 500292219101 Value Description ............................. 33 : Section TllN : Township R13E : Range MSL : Permanent Datum 0 : Elevation Of Perm. Datum RKB : Log Measured from 87.65 : Feet Above Perm. Datum KB : Drilling Measured From 87.65 : Elevation of Kelly Bushing N/A : Elevation of Derrick Floor N/A : Elevation of Ground Level N/A : Casing Depth DIRECTIONAL : Other Services Line 1 All depths are Measured Depths (MD) unless otherwise noted and are tied in to Sperry Sun's MWD DGR EWR4, February 1996. (2 Well Y-26A was drilled to 11822' MD (8900' SSTVD) on run 8 (3 The interval from 11797' MD (8906' SSTVD) to 11822' MD (8900' SSTVD) was not logged due to sensor to bit offset. (4) The data presented here is final and has not been depth shifted to a PDC (Primary Depth Control). As per BPX instructions, the MWD Gamma Ray is the PDC for this borehole. (5) A Magnetic Declination correction of 26.53 degrees has been applied to the Directional Surveys. Surface Equipment: Main Surface System Software: MSS4 Version 4.0.3. Memory Dump System Software: D-Series rev. 1.03/PowerComms Rev. 1.0 Downhole Equipment: Natural Gar~ma Ray Sensor;NaI Scintillation Counter USMPR Resistivity: 2 MHz and 400 kHz Electromagnetic Wave RWD Memory Update Rates: Gamma Ray 10 seconds Resistivity 5 seconds Note: Each of the resistivity mesurements has un upper limit to its mesurement specification. Above these values the traces can show an exagerated response. Log Environment Corrections: Gamma Ray: Corrected for sensor type and collar size. No correlation has been applied for nominal hole size, mud weight or potassium content. Resistivity: Corrected for tool size, nominal hole size and mud resistivity. Compensated readings obtained by use of dual transmitter configuration. MNEMONICS: GRAM = Gamma Ray MWD-API [MWD] (MWD-API units) RACLM = Resistivity Compensated 400 kHz Attenuation Resistivity Borehole Corrected [MWD], (ohm-m) RPCLM = Resistivity Compensated 400 kHz Phase Difference Resistivity Borehole Corrected [MWD], (ob_m-m) RACHM = Resistivity Compensated 2 MHz Attenuation Resistivity Borehole Corrected [MWD], (ob2n-m) RPCHM = Resistivity Compensated 2 MHz Phase Difference Resistivity Borehole Corrected [MWD], (ob_m-m) SENSOR OFFSETS: RUN GAMMA DIRECTIONAL N/A N/A N/A CURVE SHIFT DATA No depth shift has been applied. Tape Subfile: 1 Minimum record length: Maximum record length: 83 records... 12 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration, Inc. WN Y-26A FN Prudhoe Bay Unit COLIN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 1. The data presented is the field raw data. 2. The data has been not depth shifted. 3. Gamma Ray MWD is the Primary Depth Control curve *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP .................................................. GR GR GRAM 0.0 RACH RACH RACHM 0.0 RACL RACL RACLM 0.0 RPCH RPCH RPCHM 0.0 RPCL RPCL RPCLM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 24 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 42 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 5 Curves: Name Tool Code Samples Units Size 1 GR MWD 68 1 API 4 2 RACH MWD 68 1 F/HR 4 3 RACL COMP 68 1 4 4 RPCH COMP 68 1 4 5 RPCL COMP 68 1 4 Length 20 Total Data Records: 66 Tape File Start Depth = 10449.000000 Tape File End Depth = 11822.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 78 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 02/01/08 192557 01 **** REEL TRAILER **** MWD 02/01/08 BHI 01 Tape Subfile: 3 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Subfile 1 is type: Tape Subfile 2 is type: DEPTH GR RPCL 10449.0000 -999.2500 10449.5000 -999.2500 10500.0000 -999.2500 10600.0000 -999.2500 10700.0000 28.5900 10800.0000 205.0740 10900.0000 119.2670 11000.0000 5.9020 11100.0000 8.1810 11200.0000 7.3530 11300.0000 6.5020 11400.0000 7.8550 11500.0000 11.8160 11600.0000 6.4510 11700.0000 6.5140 11800.0000 -999.2500 11822.0000 -999.2500 LIS LIS 56 7710 55 4290 -999 2500 -999 2500 74 5470 132 6670 933 2300 21 2630 41 5010 30 4020 22 3160 36 5920 40.3550 20.0640 40.7220 168.1500 -999.2500 RACH -999.2500 -999.2500 -999.2500 -999.2500 29.1750 115.7820 453 0020 5 6640 7 8750 6 9480 6 0380 7 0810 9 9230 5 7640 5 9200 -999 2500 -999.2500 RACL -999.2500 -999.2500 -999.2500 -999.2500 37.6780 86.4530 21.4820 6 3180 6 9330 6 0920 6 2000 6 6660 9 0070 6 4970 5.5220 -999.2500 -999.2500 RPCH -999.2500 -999.2500 -999.2500 -999.2500 26.0490 158 7060 37 4720 5 4790 8 4200 7 9100 6 6970 8.6730 13.2140 5.6600 6.8720 -999.2500 -999.2500 Tape File Start Depth = 10449.000000 Tape File End Depth = 11822.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS